Apparatus and method for wirelessly communicating data between a well and the surface

ABSTRACT

In one aspect, wellbore apparatus is disclosed that includes: a conduit in the wellbore that has a non-liquid medium therein; and a transducer that is configured to transmit radio frequency signals through the medium. In another aspect, a method is disclosed that includes: placing a conduit in the wellbore that contains a non-liquid medium therein; and transmitting information in the form of radio frequency signals through the medium.

BACKGROUND OF THE DISCLOSURE

1. Field of the Disclosure

This disclosure relates to apparatus and methods for wirelesslycommunicating data between a well and the surface.

2. Background Information

Wells (also referred to as “wellbores” or “boreholes”) are drilled andcompleted to produce hydrocarbons (oil and gas) from one or moreproduction zones penetrated by a wellbore. A typical completed well mayinclude a metallic casing that lines the well. Cement is generallyplaced between the casing and the well to provide a seal between theformation surrounding the well and the casing. Perforations made in theformation through the casing at selected locations across from theproducing formations (also referred to as the “production zones” or“reservoirs”) allow the formation fluid containing the hydrocarbons toflow into the cased well. The formation fluid flows to the surface via aproduction tubing placed inside the casing because the pressure in theproduction zone is generally higher than the pressure caused by theweight of the fluid column in the well. An artificial lift mechanism,such as an electrical submersible pump (“ESP”) or a gas-lift mechanismis often employed when the formation pressure is not adequate to pushthe fluid in the well to the surface.

A variety of devices are used in the well to control the flow of thefluid from the production zones to optimize the oil and gas productionover the life of the well. Remotely-controlled flow control valves andchokes are often used to control the flow of the fluid. Chemicals areinjected at certain locations in the well via one or more tubes that runfrom the surface to the production zones to inhibit the formation ofharmful chemicals, such as corrosion, hydrate, scale, hydrogen sulfide,methane, asphaltene, etc. A number of sensors are typically placed inthe well to provide information about a variety of downhole parameters,including the position of the valves and chokes, pressure, temperature,fluid flow rate, acoustic signals responsive to water front and surfaceor downhole induced signals in the subsurface formations, resistivity,porosity, permeability, water-cut, etc. The measurement data istypically transmitted to the surface via conductors, such as electricalwires, that run from the surface to selected locations in the well.Signals are also sent from the surface to the downhole sensors anddevices via such conductors to control their operations. Such conductors(also referred to herein as data communication “links”) sometimesdegrade over time. It is therefore desirable to have a datacommunication system that may be less prone to degradation.

The present disclosure provides improved apparatus, systems and methodsfor communicating data between a well and the surface.

SUMMARY

In one aspect, a well data communication system is disclosed thatincludes a conduit placed in a well, the conduit having a non-liquidmedium therein, and a transducer that transmits wireless signals throughthe medium in the conduit that are representative of a selectedinformation. The system may further include one or more repeatersassociated with the conduit that receive the wireless signalstransmitted by the transducer and retransmit the received signalswirelessly through the medium in the conduit. The system may furtherinclude a receiver that receives the signals transmitted by thetransducer or the repeaters and a processor that processes the receivedsignals to determine the selected information or to estimate a propertyof interest. The wireless signals may be radio frequency signals. Theinformation may relate to downhole sensor measurements, downholedevices, surface sensor measurements, surface devices, stored in asuitable medium, received from a remote unit, etc. The transducer and/orany of the repeaters may be a transceiver and each may further be anautonomous device. The system may further include a transducer at thesurface that transmits wireless signals, such as radio frequencysignals, to a location in the well (a “downhole location”) via themedium in the conduit or another conduit that runs from the surface tothe downhole location. Each of the transducers and repeaters maytransmit and/or receive signals at a plurality of frequencies.

In another aspect, an apparatus is disclosed for use in a well thatincludes a conduit that has a non-liquid medium therein and whichconduit is configured to be deployed in the well, and a transmitter thatis configured to transmit wireless signals, which may be radio frequencysignals, from one a downhole location and/or a surface location via themedium in the conduit.

In another aspect, a method is disclosed that includes transmittingwireless signals relating to selected information through a non-liquidfilled conduit deployed in a well.

Examples of the more important features of a well data communicationsystem and methods have been summarized rather broadly in order that thedetailed description thereof that follows may be better understood, andin order that the contributions to the art may be appreciated. Thereare, of course, additional features that will be described hereinafterand which will form the subject of the claims. The summary is providedto provide the reader with broad information and is not intended to beused in any way to limit the scope of the claims.

BRIEF DESCRIPTION

For a detailed understanding of the apparatus and methods forcommunicating information between a well and the surface, referenceshould be made to the following detailed description, taken inconjunction with the accompanying drawings, in which like elementsgenerally have been given like numerals, wherein:

FIG. 1A shows a schematic diagram of an exemplary well that isconfigured to provide data communication between devices in the well anda surface controller according to one embodiment of the disclosure;

FIG. 1B shows a schematic diagram of certain controllers and devices atthe surface that may be utilized to establish data communication betweenthe well and the surface according to one embodiment of the disclosure;and

FIG. 2 shows a functional block diagram of a transducer that may beutilized to transmit wireless signals in a well system, such as shown inFIGS. 1A and 1B.

DETAILED DESCRIPTION OF EMBODIMENTS

FIGS. 1A and 1B (collectively referred to as “FIG. 1”) collectively showschematic diagrams of one embodiment of a well system 100 that includesa data communication system between a completed well 50 and the surface112 according to one embodiment of the disclosure. FIG. 1A shows theschematic diagram of the equipment of the well system that is below thesurface 112, while FIG. 1B shows the functional block diagram ofexemplary equipment of the well system 100 that may be placed at thesurface 112. The system 100 shows the well 50 formed in a formation 55that produces formation fluids 56 a and 56 b (such as hydrocarbons) fromtwo exemplary production zones 52 a (upper production zone) and 52 b(lower production zone) respectively. The well 50 is shown lined with acasing 57 containing perforations 54 a adjacent the upper productionzone 52 a and perforations 54 b adjacent the lower production zone 52 b.A packer 64, which may be a retrievable packer, positioned above oruphole of the lower production zone perforations 54 a, isolates thelower production zone 52 b from the upper production zone 52 a. A screen59 b adjacent to the perforations 54 b may be installed to prevent orinhibit solids, such as sand, from entering into the wellbore from thelower production zone 54 b. Similarly, a screen 59 a may be usedadjacent the upper production zone perforations 59 a to prevent orinhibit solids from entering into the well 50 from the upper productionzone 52 a.

Formation fluid 56 b from the lower production zone 52 b enters theannulus 51 a of the well 50 through the perforations 54 a and into atubing 53 via a flow control valve 67. The flow control valve 67 may bea remotely controlled sliding sleeve valve or any other suitable valveor choke that is configured to regulate the flow of the fluid from theannulus 51 a into the production tubing 53. An adjustable choke 40 inthe tubing 53 may be used to regulate the fluid flow from the lowerproduction zone 52 b to the surface 112. The formation fluid 56 a fromthe upper production zone 52 a enters the annulus 51 b (the annulusportion above the packer 64) via perforations 54 a. The formation fluid56 a enters production tubing or line 45 via inlets 42. An adjustablevalve or choke 44 regulates the fluid flow into the tubing 45. Eachvalve, choke and other devices in the well may be operated electrically,hydraulically, mechanically and/or pneumatically by a surfacecontroller, such as a control unit 150 and/or by a downhole controller,such as a control unit 60. The fluid from the upper production zone 52 aand the lower production zone 52 b enter the line 46.

When the formation pressure is not sufficient to push the fluid 56 aand/or fluid 56 b to the surface, an artificial lift mechanism, such asan electrical submersible pump (ESP), gas lift system or other desiredsystems may be utilized to lift the fluids from the well 50 to thesurface 112. In the system 10, an ESP 30 in a manifold 31 is shown asthe artificial lift mechanism, which receives the formation fluids 56 aand 56 b and pumps such fluids via tubing 47 to the surface 112. A cable134 provides power to the ESP 30 from a surface power source 132 (FIG.1B). The cable 134 also may include two-way data communication links 134a and 134 b (FIG. 1B), which may include one or more electricalconductors or fiber optic links to provide two-way signal and datacommunication between the ESP 30, ESP sensors S_(E) and an ESP controlunit 130.

Still referring to FIGS. 1A and 1B, in one aspect, a variety of sensorsare placed at suitable locations in the well 50 to provide measurementsor information relating to a number of downhole parameters of interest.In one aspect, one or more gauge or sensor carriers, such as a carrier15, may be placed in the production tubing to house any number ofsuitable sensors. The carrier 15 may include one or more temperaturesensors, pressure sensors, flow measurement sensors, resistivitysensors, sensors that may provide information about density, viscosity,water content or water cut, etc., and chemical sensors that provideinformation about scale, corrosion, hydrate, paraffin, hydrogen sulfide,emulsion, asphaltene, etc. Density sensors may provide fluid densitymeasurements for fluid produced from each production zone and that ofthe combined fluid from two or more production zones. A resistivitysensor or another suitable sensor may provide measurements relating tothe water content or the water-cut of the fluid mixture received fromeach production zones and/or for the combined fluid. Other sensors maybe used to estimate the oil/water ratio and gas/oil ratio for eachproduction zone and for the combined fluid. The temperature, pressureand flow sensors provide measurements for the pressure, temperature andflow rate of the fluid. Additional gauge carriers may be used to obtainthe above-noted and other measurements relating to the upper productionzone 52 a. Also, downhole sensors may be used at other desired locationsto provide measurements relating to the presence and extent of chemicalsdownhole. Additionally, sensors S₁-S_(m) may be permanently installed inthe wellbore 50 to provide measurements, such as acoustic, seismic ormicroseismic measurements, formation pressure and temperaturemeasurements, resistivity measurements and measurements relating to theproperties of the casing 51 and formation 55. Such sensors may beinstalled in the casing 57 or between the casing 57 and the formation55. Microseismic and other sensors may be used to detect water fronts,which may imbalance the composition of the fluids being produced,thereby providing early warning relating to the formation of certainchemicals. Pressure and temperature changes or expected changes mayprovide early warning of changes in the chemical composition of theproduction fluid. Additionally, the screen 59 a and/or screen 59 b maybe coated with tracers that are released due to the presence of water,which tracers may be detected at the surface or downhole to determine orpredict the occurrence of water breakthrough. EPS sensors S_(E) mayprovide information relating to the ESP 30, such as power to the ESP,frequency, flow rate, temperature, pressure, differential pressureacross ESP, presence of certain chemicals, such as corrosion, scale,hydrate, hydrogen sulfide, asphaltene, etc. Sensors also may be providedat the surface, such as a sensor for measuring the water content in thereceived fluid, total flow rate for the received fluid, fluid pressureat the wellhead, temperature, etc. Other devices may be used to estimatethe production of sand for each zone.

In general, sufficient sensors may be suitably placed in the well 50 andthe surface 112 to obtain measurements relating to each desiredparameter of interest. Such sensors may include, but are not limited to:sensors for measuring pressures corresponding to each production zone,pressure along the wellbore, pressure inside the tubings carrying theformation fluid, pressure in the annulus; sensors for measuringtemperatures at selected places along the wellbore; sensors formeasuring fluid flow rates corresponding to each of the productionzones, total flow rate, flow through the ESP; sensors for measuring ESPtemperature and pressure; chemical sensors for providing signalsrelating to the presence and extent of chemicals, such as scale,corrosion, hydrates, paraffin, emulsion, hydrogen sulfide andasphaltene; acoustic or seismic sensors that measure signals generatedat the surface or in offset wells and signals due to the fluid travelfrom injection wells or due to a fracturing operation; optical sensorsfor measuring chemical compositions and other parameters; sensors formeasuring various characteristics of the formations surrounding thewell, such as resistivity, porosity, permeability, fluid density, etc.The sensors may be installed in the tubing in the well or in any deviceor may be permanently installed in the well. For example, sensors may beinstalled in the wellbore casing, in the wellbore wall or between thecasing and the wall. The sensors may be of any suitable type, includingelectrical sensors, mechanical sensors, piezoelectric sensors, fiberoptic sensors, optical sensors, etc. The signals from the downholesensors may be partially or fully processed downhole by a downholecontroller, such as controller 60, which may include a microprocessorand associated electronic circuitry and programs and then communicatedto the surface controller 150 (FIG. 1A) via a signal/data link, such aslink 101. The signals from downhole sensors may also be sent directly tothe controller 150.

A variety of hydraulic, electrical and data communication lines(collectively designated by numeral 20 (FIG. 1A) are run inside the well50 to operate the various devices in the well 50 to obtain measurementsand other data from the various sensors in the well 50 and to providepower and data communication between the surface and downhole equipment.As an example, a tube or tubing 21 may supply or inject a particularchemical from the surface into the fluid 56 b via a mandrel 36.Similarly, a tubing 22 may supply or inject a particular chemical to thefluid 56 a in the production tubing via a mandrel 37. Separate lines maybe used to supply the additives at different locations in the well 50 orto supply different types of additives. Lines 23 and 24 may operate thechokes 40 and 44 and may be used to operate any other device, such asthe valve 67. Line 25 may provide electrical power to certain devicesdownhole from a suitable surface power source. One or more non-liquidfilled conduits, such as conduits 101 and 102 may be deployed in thewell to establish two-way data communication between sensors and devicesin the system. A downhole control unit, such as controller 60 and asurface controller, such as controller 150 may be used to processsignals from these sensors and devices and then transmit desiredinformation wirelessly via the conduits 101 and/or 102. The sensors andthe devices may communicate with the controllers by any suitable links,including, but not limited to, electrical conductors, optical fibers,acoustic signals, electromagnetic signals, and wireless signals.

In one aspect, one or more conduits or tubing, such as tubing 101 and102 are placed or run between a suitable location in the well 50 and thesurface to establish wireless data communication between a well 50 andthe surface 112. These tubings may be made from any suitable material,such as an alloy or a composite material capable of withstanding thedownhole environment for an extended time period. In one aspect, thetubings 101, 102 may be filled with a suitable gas, such as air or aninert gas, such as nitrogen or argon. In another aspect, the tubings101, 102 may be partially, substantially or fully evacuated. In FIG. 1,tubing 101 is shown in signal communication with a downhole transducer110, which may include an RF data transmitter an/or a transceiver. Thetransducer 110 may include a receiver that receives signals or data fromone or more sensors, such a sensors S₁-S_(m) in the well 50 and otherdevices. Such data or signals may be provided to the transducer 110 bycoupling the sensors to the transducer via electrical, fiber optic orwireless links. The transducer may be an active device and may include aprocessor, memory and other circuitry that can process the signalsreceived from the sensors, process the received signals and transmit theprocessed signals as wireless signals through the medium in the tubing101 at one or more selected frequencies. A transducer 120 (FIG. 1B)spaced from the transducer 110 receives the wireless signals and sendsthe received signals to a surface controller or control unit 150. Thesurface controller 150 decodes the signals received from the receiver120 and uses the signals to manage one or more operations of the wellsystem 100. The surface controller also may send data signals to thetransducer 120, which transmits the received signals via the non-liquidmedia in the tubing 101 as wireless signals. Alternatively, a separatetransducer 122 and tubing 102 may be used to send the wireless signalsfrom the surface 112 to a downhole controller 60 via the non-liquidmedium in the tubing 102. Each of the transducers 110 and 120 may beconfigured to transmit the wireless signals at more than one frequency.The signals may be coded signals and may use any desired signalsmodulation technique, such as amplitude, phase and frequency modulation.

Wells can be very long and can extend to several thousand meters. Insome such wells, the radio frequency signal transmitted by a transducer,such transducer 110, may attenuate and may not be detectable by thereceiver 120. In other cases, it may be desirable to transmit radiofrequency signals between a branch wellbores or a branch wellbore and amain wellbore or the surface via a conduit in which the signals mayattenuate to an undesirable extent. Also, the transducer 110 over timemay not be able to send signals that are strong enough to reach adesired receiver in the system 100. In any such cases, one or morerepeaters, such as R₁-R_(n), (generally designated by numeral 114) maybe deployed in the well 50 and configured in a manner so that they candetect signals from the conduit medium and retransmit the detectedsignals to the receiver 120. Similar transmitters may be deployed inconduit 102.

Each of the transducers, such as transducer 110, and the repeatersR₁-R_(n) may be an autonomous device. FIG. 2 shows a functional diagramof an autonomous transducer or repeater 200 according to one embodimentof the disclosure. The device 200 may include: a processor 210, such asa micro-controller, microprocessor or another suitable circuitcombination; a data storage device or memory device 212, such a solidstate memory device (Read-only-memory “ROM,” random access memory(“RAM”, flash memory, etc.) that is suitable for downhole application;and one or more computer programs or sets of instructions 214 that maybe stored in the memory 212 and which programs are accessible to theprocessor 210. The processor 210 communicates with the memory 212 andthe programs 214 via links 211 and 213 respectively. A power source 220provides power to the processor as shown by link 231 and to the othercomponents of the device 200 via link 223. In operation, signalsT₁-T_(p) from sensors and other devices may be received by an interface230 that is configured to receive such signals. The interface 230 may beconfigured to condition such signals, such as by amplifying anddigitizing the signals. The processor 210 processes receives the signalsfrom the interface and processes such signals, such as by sequencing thesignals, putting the signals in appropriate data packets, assigningaddresses of the sensors or the devices from which such signals arereceived, etc. and sends such processed signals via link 241 to atransmitter 240 that transmits the signals wirelessly via the medium inthe conduit. The wireless signals, such as radio frequency signals, sentfrom the surface via the conduits 101 and/or 102 are received by asecond interface or a receiver 245, which conditions the receivedsignals and provides them to the processor 210. The processor 210 thenmay process these signals and may control one or more downhole devices260 in response to such signals. The processor may store any informationin the memory device 212 and use any programs 214 to perform one or moreof the functions described herein. The processor 210 is shown tocommunicate with the receiver radio frequency 245 via link 243, withdownhole devices 260 via link 261. Alternatively, the signals sent fromthe surface may be received by a downhole controller 60 or received bythe transducer 110 and passed on to the controller 60. Thus, in oneaspect, the downhole transducer 110 receives signals from one or moredevices or sensors in the well or from a controller in the well andtransmits signals representative of the received signals as wirelesssignals, such as RF signals, through a non-liquid filled conduit placedin the well. A receiver spaced from the downhole transducer detects theRF signals and transmits to a surface controller for further use. Thesurface controller may send RF signals to a downhole receiver via thesame or a separate non-liquid filled conduit. One or more repeatersplaced between the transducer and the surface receiver may be used toreceive and retransmit the signals sent by the transducer.

Referring back to FIG. 1B, in one aspect, the exemplary equipment shownin FIG. 1B may be utilized to manage and control the various operationsof the well system 100 in response to the signals received from thedownhole transducer 110. In one aspect, the controller 150 may manageinjection of additives from a chemical injection unit 120 into the well50 to enhance production from one or more zones in response to thesignals received from a chemical sensor that may provide informationabout the presence of certain chemicals, such as scale, hydrate,corrosion, asphaltene, hydrogen sulfide, etc. or in response to awater-cut sensor, resistivity sensor, etc.

In another aspect, the central controller 150 may control the operationof one or more downhole devices directly or via a downhole control unit160 and lines 21-25 by sending commands via a link 161. The commands maybe instructions to alter the position of a choke or a sliding sleeve,etc and such commands may be in response to signals received from one ormore downhole sensors, surface sensors, based on programmed instructionsprovided to the controller and/or signals received from a remotecontroller, such as controller 185 that may communicate with thecontroller 150 via any suitable link 189, such as Ethernet, theInternet, etc. In another aspect, the central controller 150 may controlthe operation of the ESP 30 directly or via an ESP controller 130. TheESP controller may control power to the ESP from a power source 132 inresponse to the signals received from the ESP sensors and/or signalsreceived from the central controller 150.

Still referring to FIGS. 1 and 2, a system is disclosed that includes: anon-liquid filled-conduit (“conduit”) in a well; at least one sensorthat provides signals relating to a parameter of interest; and atransducer in the wellbore that transmits wireless signals, such asradio-frequency signals, through the non-liquid medium in the conduitthat are representative of the signals provided by the at least onesensor. The system may further include a repeater in the well thatreceives the signals transmitted by the transducer in the well andretransmits the received signals as radio frequency signals through themedium in the conduit. The system may further include a surface receiverthat receives the signals transmitted by the transducer and a processorthat process the signals received by the surface receiver to estimatethe property of interest. The sensor in the well may be a: (i) pressuresensor; (ii) temperature sensor; (iii) an acoustic sensor; (iv) a flowrate measuring sensor; (v) a water-cut measurement sensor; (vi) aresistivity measurement sensor; (vii) a chemical detection sensor;(viii) a fiber optic sensor; and (ix) a piezoelectric sensor. Theconduit may be: (i) substantially filled with air; (ii) substantiallyfilled with a gas; or (iii) at least partially evacuated. The conduitmay extend from a selected location in the wellbore to an upholelocation. The uphole location may be: (i) a location at the surface ofthe earth; (ii) a location in the wellbore uphole of the datatransmission device: (iii) a location at a sea bed; (iv) a location on aland rig; and (v) a location on an offshore platform. The sensors maycommunicate with the transducer in the well via: (i) an electrical wire;(ii) an optical fiber; and (iii) wirelessly.

Each transducer and/or repeater include: a circuit that receives thesignals from the at least one sensor; and a signal conditioner thatconditions the received signals; and a transmitter that transmitssignals as radio frequency signals through the medium in the conduit.The system may further include a power source that provides electricalpower to the transducer. The power source may be: (i) a battery; (ii) apower generation unit that generates electrical power in the wellbore;or (iii) a power unit at the surface that supplies electrical power viaan electrical conductor disposed in or along the conduit. The conduitmay be placed along a production tubing that carries fluid from thewellbore to the surface; along a casing in the well or between a casingin the well and the formation surrounding the well. Additionally, thetransducer may: (i) receive analog signals from the at least one sensorand transmit analog signals that are representative of the receivedsignals over a radio frequency; (ii) receive analog signals from the atleast one sensor and transmit digital signals that are representative ofthe received signals over a radio frequency and/or receive digitalsignals from the at least one sensor and transmit digital signals thatare representative of the received signals over a radio frequency.

In another aspect, the system may include: a plurality of sensorsdistributed in the wellbore, each sensor in the plurality of sensorsproviding the at least one? signals relating to a measurement made bysuch sensor; a conduit in the wellbore that is gas-filled or at leastpartially evacuated; a plurality of transceivers in the wellbore; andwherein each sensor in the plurality of sensors provides signals to acorresponding transceiver in the plurality of transducers, wherein eachtransceiver transmits the signals received from its associated sensorwirelessly through the conduit. Each transducer may comprise a uniqueaddress. Each transducer may be a transceiver. Energy to thetransceivers may be provided by: (i) a battery; (ii) a thermoelectricgenerator; and (iii) a combination of a battery and a thermoelectricgenerator. Any transceiver also may include a sensor for taking ameasurement relating to a parameter of interest, which may relate tohealth of the transceiver, formation or the well.

Also, a method for communicating information between a location in awellbore and an uphole location is disclosed, which method comprises:placing a non-liquid filled conduit in the wellbore; placing at leastone sensor in the wellbore that provides signals relating to a parameterof interest; placing a first device in the conduit downhole; receivingsignals provided by the at least one sensor at the first device;transmitting signals representative of the received signals wirelesslyby the first device through the conduit; and receiving the signalstransmitted by the first device at a second device uphole of the firstdevice; processing the received signals to estimate the property ofinterest; and recording the property of interest in a suitable medium.The method may further comprise one or more repeaters that receive thesignals transmitted by the first device and transmits the receivedsignals to the second device. The parameter of interest may be: (i)pressure; (ii) temperature; (iii) resistivity; (iv) fluid flow rate; (v)capacitance; (v) viscosity; (vi) density; (vii) presence of a chemicalin the wellbore; (viii) paraffin; (ix) scale; (x) hydrate; (xi) hydrogensulfide; (xii) asphaltene; (xiii) corrosion; (xiv) water content; and(xv) presence of gas.

While the foregoing disclosure is directed to certain disclosedembodiments and methods, various modifications will be apparent to thoseskilled in the art. It is intended that all modifications that fallwithin the scopes of the claims relating to this disclosure be deemed aspart of the foregoing disclosure. Also, an abstract is provided in thisapplication with the understanding that it will not be used to interpretor limit the scope or meaning of the claims.

1. A system for communicating information between a wellbore and thesurface, comprising: a conduit containing non-liquid medium placed inthe wellbore; a transducer that is configured to transmit at a firstlocation signals wirelessly through the medium in the conduit forreception of the transmitted wireless signals at a second location inthe conduit.
 2. The system of claim 1 further comprising a repeaterreceives the signals transmitted by the transducer and transmitswirelessly signals through the medium in the conduit that arerepresentative of the signals received by the repeater.
 3. The system ofclaim 1 further comprising: a surface receiver that receives the signalstransmitted by the transducer and a processor that process the signalsreceived by the surface receiver to determine the nature of the signalstransmitted by the transducer.
 4. The system of claim 1, wherein thewireless signals transmitted by the transducer relate to informationreceive from a sensor that is selected from a group consisting of: (i)pressure sensor; (ii) temperature sensor; (iii) an acoustic sensor; (iv)a flow rate measuring sensor; (v) a water-cut measurement sensor; (vi) aresistivity measurement sensor; (vii) a chemical detection sensor;(viii) a fiber optic sensor; and (ix) a piezoelectric sensor.
 5. Thesystem of claim 1, wherein the wireless signals are radio frequencysignals.
 6. The system of claim 1, wherein the conduit is one of: (i)substantially filled with air; (ii) substantially filled with a gas; and(iii) at least partially evacuated.
 7. The system of claim 1, whereinthe conduit extends from a first location in the wellbore to a secondlocation that is selected from a group consisting of: (i) a location atthe surface of the earth; (ii) a location in the wellbore uphole of thedata transmission device: (iii) a location at a sea bed; (iv) a locationon a land rig; and (v) a location on an offshore platform.
 8. The systemof claim 1, wherein the transducer receives signals to be transmittedvia one of: (i) an electrical wire; (ii) an optical fiber; and (iii)wirelessly.
 9. The system of claim 1, wherein the transducer furthercomprises: a circuit configured to receive the signals from at least onesensor; and a signal conditioner configured to condition the receivedsignals; and a transmitter configured to transmit the conditionedsignals as radio frequency signals through the medium in the conduit.10. The system of claim 1 further comprising a power source thatprovides electrical power to the transducer, wherein the power source isselected from a group consisting of: (i) battery; (ii) a powergeneration unit that generates electrical power in the wellbore; and(iii) a power unit at the surface that supplies electrical power via anelectrical conductor disposed in or along the conduit.
 11. The system ofclaim 1, wherein the conduit is placed in the well in a manner that isone of: (i) along a production tubing that carries fluid from the wellto the surface; (ii) along a casing in the wellbore; and (iii) between acasing and formation surrounding the well.
 12. The system of claim 1,wherein the transducer performs at least one function that is selectedfrom a group of functions consisting of: (i) receives analog signalsfrom at least one sensor and transmits analog signals that arerepresentative of the received signals over a radio frequency; (ii)receives analog signals from at least one sensor and transmits digitalsignals that are representative of the received signals over a radiofrequency; and (iii) receives digital signals from at least one sensorand transmits digital signals that are representative of the receivedsignals over a radio frequency.
 13. A method for communicatinginformation between a downhole location in a well and an upholelocation, the method comprising: placing a conduit in the well, whichconduit contains a non-liquid medium; transmitting wireless signalstrough the medium in the conduit at a first location that arerepresentative of selected information; and receiving the signalstransmitted through the medium at a second location in the conduit;processing the received signals to obtain a parameter of interest; andrecording the parameter of interest in a suitable medium.
 14. The methodof claim 13 further comprising receiving the wireless signals at arepeater between the first and second locations and retransmitting suchreceived signals wirelessly through the medium.
 15. The method of claim13, wherein the parameter of interest is selected from a groupconsisting of: (i) pressure; (ii) temperature; (iii) resistivity; (iv)fluid flow rate; (v) capacitance; (v) viscosity; (vi) density; (vii)presence of a chemical in the wellbore; (viii) paraffin; (ix) scale; (x)hydrate; (xi) hydrogen sulfide; (xii) asphaltene; (xiii) corrosion;(xiv) water content; and (xv) presence of gas.
 16. The method of claim13, wherein the conduit is placed in a manner that is one of: (i) insidea casing in the well; (ii) between a casing in the well and theformation surrounding the well; (iii) inside a production tubing thatcarries the well fluid.
 17. A method for communicating data between awell and a surface location, comprising: placing a conduit in the wellthat contains a non-liquid medium therein; and transmitting wirelesssignals representative of a desired information as wireless signalsthrough the non-liquid medium in the conduit.
 18. The method of claim 17further comprising detecting the wireless signals in the conduit andprocessing the detected signals to ascertain the desired information.19. The method of claim 18 further comprising recording the desiredinformation in a suitable medium.
 20. The method of claim 18 furthercomprising controlling an operation of a well system in response toprocessed signals.
 21. An apparatus for use in a well, comprising: aconduit containing a non-liquid therein and configured for deployment inthe well; and a transmitter configured to transmit informationwirelessly through the non-liquid medium in the conduit at a selectedlocation in the conduit.
 22. The apparatus of claim 21 furthercomprising receiving the wireless signals at second location spaced fromthe selected location and retransmitting the received signals wirelesslythrough the non-liquid medium in the conduit.